Búsqueda Imágenes Maps Play YouTube Noticias Gmail Drive Más »
Iniciar sesión
Usuarios de lectores de pantalla: deben hacer clic en este enlace para utilizar el modo de accesibilidad. Este modo tiene las mismas funciones esenciales pero funciona mejor con el lector.

Patentes

  1. Búsqueda avanzada de patentes
Número de publicaciónUS4351401 A
Tipo de publicaciónConcesión
Número de solicitudUS 06/159,181
Fecha de publicación28 Sep 1982
Fecha de presentación13 Jun 1980
Fecha de prioridad8 Jun 1978
Número de publicación06159181, 159181, US 4351401 A, US 4351401A, US-A-4351401, US4351401 A, US4351401A
InventoresCoy M. Fielder
Cesionario originalChristensen, Inc.
Exportar citaBiBTeX, EndNote, RefMan
Enlaces externos: USPTO, Cesión de USPTO, Espacenet
Earth-boring drill bits
US 4351401 A
Resumen
The invention relates to the design of earth bore-hole drill bits embodying shaped preformed cutters containing hard abrasive materials, such as diamonds, the cutters being mounted in companion preformed sockets in the hard metal bit matrix. The extent of penetration of the preformed cutters into the formation being drilled is controlled by providing surface set diamonds embedded in the matrix at or adjacent to its gage portion, the surface set diamonds projecting from the matrix to a much lesser extent than the preformed cutters. As a result, the surface set diamonds can penetrate into the formation only to the extent determined by engagement of the adjacent face of the matrix with the formation. Although the preformed cutters project from the matrix to a greater distance than the surface set diamonds, their extent of penetration into the formation is no greater than that of the surface set diamonds.
Imágenes(4)
Previous page
Next page
Reclamaciones(6)
I claim:
1. An earth-boring bit comprising a metallic shank having a fluid passage, one end of said shank being coated with a hard material bonded to said end and forming a face of said bit, said hard material having a wear resistance substantially greater than that of said metallic shank, preformed sockets in said hard material of said face, preform cutters mounted in said sockets and extending to substantially the gage of the bit, each of said cutters including a plurality of abrasive particles bonded into a preform, and penetration control diamonds embedded in said hard material adjacent to the gage of the bit and extending around the gage of the bit, said control diamonds projecting from said hard material, the extent of projection of said control diamonds from said hard material being substantially less than the extent of projection of said preform cutters from said hard material.
2. An earth-boring bit comprising a metallic shank having a fluid passage, one end of said shank being coated with a hard material bonded to said end and forming a face of said bit, said hard material having a wear resistance substantially greater than that of said metallic shank, preform cutters mounted in said hard material and extending to substantially the gage of the bit, each of said cutters including a plurality of abrasive particles bonded into a preform, and penetration control diamonds embedded in said hard material adjacent to the gage of the bit and extending around the gage of the bit, said control diamonds projecting from said hard material, the extent of projection of said control diamonds from said hard material being substantially less than the extent of projection of said preform cutters from said hard material.
3. The bit of claims 1 or 2, said preform cutters comprising bonded diamond particles.
4. The bit of claims 1 or 2, said preform cutters comprising bonded synthetic diamond particles.
5. The bit of claims 1 or 2, said hard material being fabricated at above about 2000° F.
6. The bit of claims 1 or 2, a plurality of fluid channels positioned in said face and extending to the gage of said bit, said fluid channels communicating with said fluid passage, said fluid channels extending in front of said preform cutters.
Descripción

This application is a division of application Ser. No. 913,571, filed June 8, 1978, for "Earth Boring Drill Bits", now U.S. Pat. No. 4,244,432, which is a continuation of application Ser. No. 704,424, filed July 12, 1976, for "Earth-Boring Drill Bits", now abandoned.

BACKGROUND OF THE INVENTION

Diamond bits employing natural or synthetic diamonds positioned on the face of a drill shank and bonded to the shank in a matrix of a secondary abrasive, such as tungsten carbide, by means of a metal bond, are well known in the art.

There are two general types: One in which the diamonds usually of very small gage are randomly distributed in the matrix; another type contains diamonds, usually of larger size, positioned in the surface of the drill shank in a predetermined pattern, referred to as surface set. (see U.S. Pat. Nos. 3,709,308; 3,825,083; 3,871,840; 3,757,878; and 3,757,879.)

Drill bits formed according to the above procedure are subject to damage when used as bore-hole drill bits. Such damage results from localized destruction of the diamond matrix complex. When this occurs, the useful life of the bit may be terminated and salvage of the bit is required by separating the diamonds and tungsten carbide from the steel shank.

STATEMENT OF THE INVENTION

Instead of using individual diamond particles distributed either in random orientation in the secondary abrasive matrix, such as tungsten carbide with a metallic bonding agent, or as surface set bits, a cutter preform is employed. The cutter preform may be made as described in U.S. Pat. No. 3,745,623 or by molding mixtures of diamond particles, secondary abrasive particles, and particles of a metallic bonding agent employing the techniques of the above patents in suitable shaped molds, for example, by the hot press methods described in U.S. Pat. Nos. 3,841,852 and 3,871,840. A preform is preferred formed as in U.S. Pat. No. 3,745,623. According to the invention, the preforms are mounted in the body of the drill bit, such as described above, to be placed in spaced relation from the part adjacent to the central axis to close to gage of the bit. The arrangement of the preforms in the bit is such that on rotation of the bit about its axis, substantially the entire surface of the earth traversed by the bit on rotation is engaged by the preforms.

In order to assure that the preforms can cut without undue stress, the preforms are set at a negative rake and the preforms are backed by an adjacent portion of the body of the bit to take the thrust on the preform cutters imposed during drilling. Bending stresses are thus minimized, and, in a practical sense, avoided in the preforms.

Provisions are made to move the cuttings away from the preforms, the drilling fluid discharging from a fluid passage in the bit to provide a flushing action. For this purpose, channels are provided in fluid communication with the passage in front of the cutter preforms. The channels extend across the face of the bit from the central bore to the gage of the bit. While, for some uses, the channels may be omitted, the channels, as in our preferred embodiments, aid in establishing the bit hydraulics to clean the face of the bit and flush the cuttings from the drilling region. The cutters may be set with a zero but preferably with a negative side rake, so as to provide for a snowplow effect to move the cutting to the outer gage of the bit. The channels in the preferred embodiment extend in front of the cutter preforms which are oriented as described above. The orientation of the rake and the flow of fluid through the channels move the cuttings to the annulus between the bit and bore hole to be carried up the annulus to the surface. The preform cutters are carried in preformed sockets positioned in the base of the drill bit, preferably in a drill bit coated, for example, with metal-bonded secondary abrasives having a hardness value less than diamonds. Coating of the drill bit with such hard material is conventional, but in such case, the diamonds are mounted as described in the above patents. We prefer to prepare sockets in the drill, so oriented about the drill bit, and with the preforms so oriented in the sockets, as to give the pattern previously referred to.

The cutters according to our invention may be mounted in preformed sockets formed in the matrix-coated drill, so formed as to orient the preforms which are mounted by insertion into the sockets, to provide the pattern and rakes described above. Instead, the preforms may be mounted in receptacles positioned on studs which are inserted in sockets formed in the matrix-coated drill. The studs and sockets are formed so that on insertion of the studs in the receptacles, the preforms are oriented in the pattern and with the rakes described above.

It is preferred to use the bits carrying the studs in relatively soft formations and to use the preforms mounted directly in the sockets for hard formations.

The arrangements, both that employing preform cutters mounted on studs positioned in the sockets and the preforms mounted directly in the sockets formed in the face of the bit, have the advantage that the cutters may be backed so that they are in compression rather than in tension due to bending.

It is preferred to arrange the cutters in an array in the manner and for the purposes described above and more fully described below and to arrange the fluid channels to be positioned in front of the cutter arrays. This arrangement controls the flow pattern across the cutting surface in immediate proximity of the cutters and aids in removing cuttings and flushes them away from the cutters.

One of the avantages of the mounted preform cutters according to the invention is that, on destruction or other damages to a preform, the damaged preform may be removed and replaced without requiring the salvage of the entire bit.

The above design of the diamond bit of our invention is particularly suitable when using synthetic diamonds, such as are employed in the formation of the cutting elements described in U.S. Pat. No. 3,745,623. Such diamonds are weakened to a much greater degree than are natural diamonds at temperatures normally employed in production of drill bits by processes such as are described in U.S. Pat. Nos. 3,709,308; 3,824,083; and 3,757,879. Such processes entail exposing diamonds to temperatures which are used in the infiltration or hot press processes of the aforesaid patents. The temperatures employed in such procedures are in the order of above about 2000° F., for example, 2150° F. Such temperatures, while suitable for natural diamonds, are excessive for synthetic diamonds and weaken them excessively.

The design of the drill bit of the invention permits the use of synthetic diamonds as well as natural diamonds in that the preforms using synthetic diamonds or natural diamonds may be formed at temperatures suitable for synthetic diamonds as is described in said U.S. Pat. No. 3,745,623.

The design of the invention thus permits the formation of the drill bit body at high temperatures and the formation of the preforms when using natural diamonds by the high temperature methods previously described, or when using synthetic diamonds by forming them at lower temperatures, for example, as described in U.S. Pat. No. 3,745,623. Thus the preforms employing, for example, natural diamonds may be formed by the hot press method referred to in U.S. Pat. No. 3,871,840 employing molds of suitable shape to form the preform of the desired geometric configuration.

In some formations, preformed cutters of the bits may generate cuttings so rapidly that they cannot be removed quickly enough by the circulating fluid from the hole bottom. In soft ductile formations, preformed diamond cutters can generate cuttings much faster than they can be removed by the fluid, resulting in the bit balling and virtually ceasing its drilling action. With the present invention, the placing of natural surface set penetration control diamonds in the bit matrix, at or near the gage of the bit, can drastically reduce and control the extent of penetration of the preformed cutters into the formation and the rate at which such cutters can drill the hole, permitting the circulating fluid issuing from the bit an opportunity to flush the cutters clean and convey the cuttings to the gage portion of the bit and the upwardly through the annulus surrounding the drilling string. As a result, balling of the bit is prevented, the bit performance being greatly improved.

Other features and objects of the invention will be understood by reference to the drawings of which:

FIG. 1 is a view partly in elevation and partly in quarter section of an earth-boring bit according to our invention;

FIG. 2 is a plan view of the bottom of the bit taken on line 2--2 od FIG. 1;

FIG. 3 is a fragmentary section taken on line 3--3 of FIG. 1 with parts in elevation;

FIG. 4 is a section taken on line 4--4 of FIG. 3;

FIG. 5 is a section taken on line 5--5 of FIG. 4;

FIG. 6 is a fragmentary detail of FIG. 2 showing the side rake;

FIG. 7 is a fragmentary section taken on line 7--7 of FIG. 2;

FIG. 8 is a section similar to FIG. 1 prior to installation of the studs;

FIG. 9 is a vertical section of another form of a bit according to our invention;

FIG. 10 is a plan view taken on line 10--10 of FIG. 9;

FIG. 11 is an enlarged fragmentary detail taken on line 11 of FIG. 10;

FIG. 12 is a section taken on line 12--12 of FIG. 11;

FIG. 13 is a section taken on line 13--13 of FIG. 12.

In the form of FIGS. 1-7, the tubular shank 1 of the bit is of conventional shape and is connected to the drill collar 2 and is coated internally and externally of the shank with a hard material 3, for example, such as metal-bonded tungsten carbide to form the face 4 of the bit section and the stabilizer section 5, as in prior art diamond drill bits used for earth bore-hole drilling. The hard coating 3 of the bit extends circumambiently about the central axis of the bit and is positioned between the gage 6 of the bit and across the face of the bit, the gage 6 being formed on the stabilizer section 5 of the hard coating.

Sockets 7 are positioned in the coating 3 spaced as herein described in the face 4 in accordance with a pattern for the purposes herein described. The cutters 8 are mounted in the receptacles 9 carried on studs 14 positioned in sockets 7. We prefer, especially where the cutters are mounted in studs as described below, to form the face of the bit in steps 26 extending circumambiently about the face of the bit, as is described in a copending application filed jointly with applicant and another, Ser. No. 745,087. As is shown in the copending application and in FIGS. 1, 2, 7 and 8, the steps extend as a spiral from an inner portion 10 of the bit 1 to the portion of the face of the bit adjacent the gage 6, as will be more fully described below. The sockets in the case of the bit shown in FIGS. 1-7, are formed in the angle between 1 and 31 on one step and the rise 30 of the adjacent step.

In the form shown in FIGS. 1-7, each of the cutters is positioned in a stud-mounted receptacle. The studs 14 are formed with a receptacle 9 whose axis 16 is at an obtuse angle to the central axis of the stud 14. The stud is formed of steel or material of similar physical properties and is coated with a hard surface coating 18 formed, for example, of material of the same kind as is used in the coating 3. The stud may be held securely in the socket by an interference fit or by brazing or other means of securing the stud in the socket.

Secured in the receptacles as by soldering or brazing are preform cutters 8 formed as described above. They may be of any desired geometric configuration to fit into the receptacle. For convenience, we prefer cylindrical wafers whose axial dimension is but a minor fraction of the diameter of the wafer. The acute angle 20 thus established a negative vertical cutting rake.

The studs 14 are provided with indexing means, for example, flat sections 21 (FIG. 4) so as to orient the studs, as is described below. Positioned in the sockets 7 are means which cooperate with indexing means on the studs, for example, the flat section 22 (FIG. 4). The indexing means are arranged to position the studs in a longitudinal array extending from adjacent the gage 6, across the face 4 towards the axis of the bit.

The aforesaid longitudinal array extends circumambiently about the bit spaced from each other as is illustrated in FIGS. 1 and 2. The arrays are separated by fluid channels 23 which extend from the central portion 10 of the bit to the gage 6 of the bit at the stabilizer section 5, where they join the vertical grooves or fluid channels 24. The studs are positioned in each array and are spaced from each other in each array. The cutters are arranged in each longitudinal array so that they are in staggered position with respect of the cutters in an adjacent array. The cutters in the arrays overlap each other in the sense that the portion of the earth, not traversed by a cutter of one array, is traversed by a cutter in the following array during rotation.

The indexing flats in the socket and stud are positioned so that the cutting face of the preform cutters in each array face in the same angular direction as the intended direction of rotation of the bit. The bit is designed for rotation in the usual manner by a clockwise rotation of the drilling string connected to the collar 2. This arrangement assures that all sections of the surface to be cut by the bit are traversed by a series of cutters during each revolution of the bit.

A convenient arrangement is to position the sockets and studs in a generally spiral configuration extending from the center of the bit to the gage.

While the studs may be mounted in sockets formed in the face of the bit in any geometric form, for example, that shown in FIGS. 8 and 12, or in any form employed in the prior art, we prefer to mount the studs in sockets formed in the face as described and claimed in the copending application, Ser. No. 745,087.

In the form shown in FIGS. 1 and 2, the face is formed with a central portion 10 having a substantially circular perimeter 25. The portion of the face of the bit extending from the perimeter 25 to the gage 6 of the bit is formed with steps 26 in a spiral configuration. As is shown in FIG. 2, the spiral 27 starts at the tangent 29 at the rise 30 and traverses the face 4 as a spiral to form the lands 31.

The sockets 7 are formed in the face of the bit with the axis of each socket intersecting the apex of the angle between the rise and the land of each step. The geometry of this arrangement allows the bit to constitute a jig to assure that the sockets will be in a spiral configuration. The positioning of the studs in the angle between the rise and the land aids in the protection of the preform. Impact loads are absorbed by the lands and rises where the studs are located. As a result of this arrangement, on rotation of the bit, the preform cutter elements follow each other to cut the spaces which had been missed by the cutters of the preceding array. The result is that all portions of the earth are traversed by a series of cutters during each revolution of the bit.

In order to facilitate the cleaning of the bit and prevent clogging between the cutters, we provide, as described above, fluid channels 23 which join the grooves 24 in the stabilizer section 5. The fluid channels are in the form of grooves positioned between adjacent longitudinal arrays of cutters and extending adjacent to the face of the cutters in the array. Nozzles 34 (see FIGS. 1, 2 and 7) are positioned in the body of the face to connect with each channel. The nozzles are connected by bores 35 with the central tubular bore of the shank 1. They are positioned at various radial distances from the center around the bit in a generally spiral arrangement.

The flushing action of the fluid in the channels 23 may be sufficient to clean the cutters 8 and prevent clogging. In such case, the face of the cutters may be set at a zero rake, that is perpendicular to the direction of rotation, or with the negative side rake described below. Drilling fluid is discharged from the nozzles 34 into the channels or fluid courses 23 to flush cuttings through such channels and from the adjacent region of the bit, the flow of the cutting laden fluid continuing upwardly through the fluid courses 24 and along the stabilizer 5, and through the annulus between the drill string and the bore-hole wall to the surface.

To facilitate the discharge of the cuttings and to clean the bit, the cutters, in addition to the vertical negative rake 20 shown in FIG. 3, may be set in a horizontal rake as shown in FIG. 6. In order to assist in moving the cutting to the gage 6 of the bit, we prefer to orient the cutters so that the cutting surfaces of the preform cutters 8 are rotated about a vertical axis counterclockwise to provide a negative sideways rake 36 (see FIG. 6).

The negative horizontal rake angle 36 may be, for example about 1° to 10°, preferably about 20°. The effect of the negative sideways rake is to introduce a snowplow effect and to move the cuttings toward the gage of the bit where they may be picked up by the circulating fluid and carried up the grooves 24 of the stabilizer 5. The vertical negative rake angle 20 may be from about 4° to about 20°.

As will be seen, the space taken by the receptacle and the preforms makes impractical the positioning of a large multiple of preform cutting elements at the center of the bit. The problem is aggravated if any of the preforms are lost from the central portion because of damage occurring during use. It is preferred to supplement the cutting effect at the center by locating surface set diamonds 37, either in a pattern or in random distribution, in the central portion of the hard material 3. Surface set diamonds are also positioned in the matrix 3 at the gage 6 where the side impacts during drilling are large, employing conventional techniques in setting the diamonds as described above.

Through use of the infiltration method, such as described in U.S. Pat. No. 3,757,879, the hard metal coating or matrix 3 is cast on the shank 1, the casting operation also forming the steps 26, sockets 7, fluid courses 23, 24 and fluid passages 34, 35 in the matrix. At the same time, the diamonds 37 and diamonds 6a, 6b at the gage 5 are surrounded by and embedded in the matrix to securely fasten the diamonds thereto. The preformed cutters 8, 9 are then mounted in the sockets and secured therein.

One of the features of the above construction is that, should any one or more of the preform cutters be destroyed or the studs damaged, they may be removed; and a new stud and preform may be inserted.

The form of cutters of our invention, which is the presently preferred form, especially for use in hard formations, employs preforms mounted directly in position on the face of the bit.

As shown in FIGS. 9 and 10, the bit is formed by a shank 101. coated as in the form of FIG. 1 by a hard coating 102. The face of the bit 103 is of generally conical shape faring into the central opening 104. As is shown in FIG. 10, the central opening may be the form of a threefold manifold with three branches 104 communicating with channels 105 extending to and communicating with the vertical grooves or fluid courses 107 in the stabilizer section 108 of the drill bit.

On the face of the bit are formed protuberances 109 spaced in longitudinal arrays about the face of the bit. Each of the protuberances has an extension 110 leading from a socket 111 in which is mounted a preform cutter 112 of the above composition, the protuberance and socket being preformed. As is shown in FIGS. 11, 12 and 13, the entire back of the preform is supported by the wall of the socket 111 and the extension 110 which acts as a receptacle to receive the preform.

As in the case of the cutters of FIGS. 1-7, the receptacles support the cutters with both vertical and horizontal rakes as is described for the cutters of FIGS. 1-7. As is shown in FIG. 12, the preform is mounted with a vertical negative rake 120 and, as is shown in FIG. 11, with a horizontal negative rake 136. The rake angles may be as described above for the forms of FIGS. 1-8. As is shown in FIGS. 10 to 12, the protuberances in the hard material extend from the periphery of the preforms 112 to the adjacent face of the bit.

The protuberances 109 are spaced in a longitudinal array from each other adjacent the channels 105, about the face of the bit. The protuberances and their contained receptacles are spaced from each other in arrays, as is described for the form of FIGS. 1-8. The cutters positioned in the receptacles in the protuberances are thus arrayed in a staggered overlapping arrangement with respect of the cutters in the protuberances in adjacent longitudinal arrays, similar to the arrangement of the stud supported preforms. The cutting surface of the cutters faces in the same angular direction as the direction of rotation of the bit. Fluid channels 105 are positioned in front of the array of cutters 112. The fluid which is fed through the central bore of the tubular drill shank 101 discharges into the manifold 104 and thus through the channel 105 and 107 to flush the cuttings, which have been moved towards the gage 106, upward into the surrounding annulus.

In both forms, the cutters are preforms which may be replaced as they are damaged or lost. They permit the cutters to be placed in receptacles formed in the hard coating of the diamond bit, in a predetermined array to efficiently cut an entire surface. The preforms may use fine primary abrasives such as diamonds or equivalent hard abrasive particles in a preform arranged in a predetermined array on the bit. The use of such preforms mounted in a pattern to cover substantially the entire surface to be cut, but which would permit replacement of individual damages cutters, has the advantage that a worn bit may be readily repaired and need not be discarded or require salvage. In order to permit the mounting or preforms which tend to be brittle in a bit where they will meet impact forces, the invention provides for a support which preserves the integrity of the preforms.

As previously noted, surface set diamonds 6a, 6b are positioned in the matrix 3 at the gage 6. As shown in FIG. 10, surface set control diamonds 6a are located in the matrix at the gage 6 itself. Others surface set diamonds 6b may be disposed immediately inwardly of the gage, the dimaonds 6a, 6b extending arcuately around and near the gage. If the design of the bit requires, a large number of such surface set diamonds 6a, 6b can be embedded in the matrix, the extent of projection of such diamonds from the matrix being much less than the extent of projection of the preformed cutters 112. Thus, the maximum penetration of the preformed cutters 112 into the formation is controlled by the extent of penetration of the surface set control diamonds 6a, 6b into the formation, before the matrix face of the bit engages the formation.

Citas de patentes
Patente citada Fecha de presentación Fecha de publicación Solicitante Título
US2511991 *25 Feb 194820 Jun 1950Leon NussbaumRotary drilling tool
US3696875 *17 Nov 196910 Oct 1972Petroles Cie FrancaiseDiamond-studded drilling tool
US3709308 *2 Dic 19709 Ene 1973Christensen Diamond Prod CoDiamond drill bits
US3885637 *4 Ene 197427 May 1975Barkov Vasily AndreevichBoring tools and method of manufacturing the same
US3938599 *27 Mar 197417 Feb 1976Hycalog, Inc.Rotary drill bit
US4073354 *26 Nov 197614 Feb 1978Christensen, Inc.Earth-boring drill bits
US4098363 *25 Abr 19774 Jul 1978Christensen, Inc.Diamond drilling bit for soft and medium hard formations
Citada por
Patente citante Fecha de presentación Fecha de publicación Solicitante Título
US4442909 *21 Sep 198117 Abr 1984Strata Bit CorporationDrill bit
US4471845 *25 Mar 198218 Sep 1984Christensen, Inc.Rotary drill bit
US4505342 *22 Nov 198219 Mar 1985Nl Industries, Inc.Drill bit
US4511006 *17 Ene 198316 Abr 1985Grainger Alfred JDrill bit and method of use thereof
US4558753 *22 Feb 198317 Dic 1985Nl Industries, Inc.Drag bit and cutters
US4640375 *8 Feb 19843 Feb 1987Nl Industries, Inc.Drill bit and cutter therefor
US4667756 *23 May 198626 May 1987Hughes Tool Company-UsaMatrix bit with extended blades
US4676324 *29 Ene 198630 Jun 1987Nl Industries, Inc.Drill bit and cutter therefor
US4705122 *14 Ene 198610 Nov 1987Nl Petroleum Products LimitedCutter assemblies for rotary drill bits
US4718505 *12 Jul 198512 Ene 1988Nl Petroleum Products LimitedRotary drill bits
US4877096 *7 Abr 198931 Oct 1989Eastman Christensen CompanyReplaceable cutter using internal ductile metal receptacles
US4991670 *8 Nov 198912 Feb 1991Reed Tool Company, Ltd.Rotary drill bit for use in drilling holes in subsurface earth formations
US5213171 *23 Sep 199125 May 1993Smith International, Inc.Diamond drag bit
US5238074 *6 Ene 199224 Ago 1993Baker Hughes IncorporatedMosaic diamond drag bit cutter having a nonuniform wear pattern
US5431239 *8 Abr 199311 Jul 1995Tibbitts; Gordon A.Stud design for drill bit cutting element
US5460233 *30 Mar 199324 Oct 1995Baker Hughes IncorporatedDiamond cutting structure for drilling hard subterranean formations
US5595252 *28 Jul 199421 Ene 1997Flowdril CorporationFixed-cutter drill bit assembly and method
US5607025 *5 Jun 19954 Mar 1997Smith International, Inc.Drill bit and cutting structure having enhanced placement and sizing of cutters for improved bit stabilization
US5649604 *3 Oct 199522 Jul 1997Camco Drilling Group LimitedRotary drill bits
US5678645 *13 Nov 199521 Oct 1997Baker Hughes IncorporatedMechanically locked cutters and nozzles
US5906245 *21 Oct 199725 May 1999Baker Hughes IncorporatedMechanically locked drill bit components
US6009962 *28 Jul 19974 Ene 2000Camco International (Uk) LimitedImpregnated type rotary drill bits
US6062325 *16 Abr 199816 May 2000Camco International (Uk) LimitedRotary drill bits
US6123160 *2 Abr 199726 Sep 2000Baker Hughes IncorporatedDrill bit with gage definition region
US620611730 Jul 199927 Mar 2001Baker Hughes IncorporatedDrilling structure with non-axial gage
US629893026 Ago 19999 Oct 2001Baker Hughes IncorporatedDrill bits with controlled cutter loading and depth of cut
US646063115 Dic 20008 Oct 2002Baker Hughes IncorporatedDrill bits with reduced exposure of cutters
US65684922 Mar 200127 May 2003Varel International, Inc.Drag-type casing mill/drill bit
US665919913 Ago 20019 Dic 2003Baker Hughes IncorporatedBearing elements for drill bits, drill bits so equipped, and method of drilling
US67796137 Oct 200224 Ago 2004Baker Hughes IncorporatedDrill bits with controlled exposure of cutters
US69354414 Jun 200430 Ago 2005Baker Hughes IncorporatedDrill bits with reduced exposure of cutters
US7070011 *17 Nov 20034 Jul 2006Baker Hughes IncorporatedSteel body rotary drill bits including support elements affixed to the bit body at least partially defining cutter pocket recesses
US709697830 Ago 200529 Ago 2006Baker Hughes IncorporatedDrill bits with reduced exposure of cutters
US721656514 Mar 200615 May 2007Baker Hughes IncorporatedMethods of manufacturing and repairing steel body rotary drill bits including support elements affixed to the bit body at least partially defining cutter pocket recesses
US73606089 Sep 200422 Abr 2008Baker Hughes IncorporatedRotary drill bits including at least one substantially helically extending feature and methods of operation
US7395882 *19 Feb 20048 Jul 2008Baker Hughes IncorporatedCasing and liner drilling bits
US752034520 Mar 200721 Abr 2009Baker Hughes IncorporatedFixed cutter rotary drill bit including support elements affixed to the bit body at least partially defining cutter pocket recesses
US759455421 Feb 200729 Sep 2009Baker Hughes IncorporatedCutting element insert for backup cutters in rotary drill bits, rotary drill bits so equipped, and methods of manufacture therefor
US7617747 *23 Ago 200717 Nov 2009Baker Hughes IncorporatedMethods of manufacturing rotary drag bits including a central region having a plurality of cutting structures
US76213482 Oct 200724 Nov 2009Smith International, Inc.Drag bits with dropping tendencies and methods for making the same
US762135111 May 200724 Nov 2009Baker Hughes IncorporatedReaming tool suitable for running on casing or liner
US762481823 Sep 20051 Dic 2009Baker Hughes IncorporatedEarth boring drill bits with casing component drill out capability and methods of use
US7625521 *5 Jun 20031 Dic 2009Smith International, Inc.Bonding of cutters in drill bits
US770355711 Jun 200727 Abr 2010Smith International, Inc.Fixed cutter bit with backup cutter elements on primary blades
US774847530 Oct 20076 Jul 2010Baker Hughes IncorporatedEarth boring drill bits with casing component drill out capability and methods of use
US781499021 Ago 200619 Oct 2010Baker Hughes IncorporatedDrilling apparatus with reduced exposure of cutters and methods of drilling
US781499714 Jun 200719 Oct 2010Baker Hughes IncorporatedInterchangeable bearing blocks for drill bits, and drill bits including same
US783697929 Oct 200823 Nov 2010Baker Hughes IncorporatedDrill bits and tools for subterranean drilling
US790070323 Nov 20098 Mar 2011Baker Hughes IncorporatedMethod of drilling out a reaming tool
US7926596 *29 Ago 200819 Abr 2011Smith International, Inc.Drag bit with utility blades
US795457020 Sep 20067 Jun 2011Baker Hughes IncorporatedCutting elements configured for casing component drillout and earth boring drill bits including same
US795457112 Feb 20087 Jun 2011Baker Hughes IncorporatedCutting structures for casing component drillout and earth-boring drill bits including same
US799735820 Oct 200916 Ago 2011Smith International, Inc.Bonding of cutters in diamond drill bits
US800678529 May 200830 Ago 2011Baker Hughes IncorporatedCasing and liner drilling bits and reamers
US801127520 Feb 20086 Sep 2011Baker Hughes IncorporatedMethods of designing rotary drill bits including at least one substantially helically extending feature
US806593527 Feb 200929 Nov 2011Baker Hughes IncorporatedMethod of manufacturing a rotary drill bit
US806608418 Oct 201029 Nov 2011Baker Hughes IncorporatedDrilling apparatus with reduced exposure of cutters and methods of drilling
US807943022 Abr 200920 Dic 2011Baker Hughes IncorporatedDrill bits and tools for subterranean drilling, methods of manufacturing such drill bits and tools and methods of off-center drilling
US81002021 Abr 200924 Ene 2012Smith International, Inc.Fixed cutter bit with backup cutter elements on secondary blades
US810917712 Oct 20057 Feb 2012Smith International, Inc.Bit body formed of multiple matrix materials and method for making the same
US814166512 Dic 200627 Mar 2012Baker Hughes IncorporatedDrill bits with bearing elements for reducing exposure of cutters
US814668822 Abr 20093 Abr 2012Baker Hughes IncorporatedDrill bit with prefabricated cuttings splitter and method of making
US81670597 Jul 20111 May 2012Baker Hughes IncorporatedCasing and liner drilling shoes having spiral blade configurations, and related methods
US817200829 Sep 20118 May 2012Baker Hughes IncorporatedDrilling apparatus with reduced exposure of cutters and methods of drilling
US817700127 Abr 201115 May 2012Baker Hughes IncorporatedEarth-boring tools including abrasive cutting structures and related methods
US81916542 May 20115 Jun 2012Baker Hughes IncorporatedMethods of drilling using differing types of cutting elements
US82016105 Jun 200919 Jun 2012Baker Hughes IncorporatedMethods for manufacturing downhole tools and downhole tool parts
US82056937 Jul 201126 Jun 2012Baker Hughes IncorporatedCasing and liner drilling shoes having selected profile geometries, and related methods
US82258877 Jul 201124 Jul 2012Baker Hughes IncorporatedCasing and liner drilling shoes with portions configured to fail responsive to pressure, and related methods
US82258887 Jul 201124 Jul 2012Baker Hughes IncorporatedCasing shoes having drillable and non-drillable cutting elements in different regions and related methods
US824579723 Oct 200921 Ago 2012Baker Hughes IncorporatedCutting structures for casing component drillout and earth-boring drill bits including same
US827281612 May 200925 Sep 2012TDY Industries, LLCComposite cemented carbide rotary cutting tools and rotary cutting tool blanks
US82973807 Jul 201130 Oct 2012Baker Hughes IncorporatedCasing and liner drilling shoes having integrated operational components, and related methods
US831789310 Jun 201127 Nov 2012Baker Hughes IncorporatedDownhole tool parts and compositions thereof
US831806324 Oct 200627 Nov 2012TDY Industries, LLCInjection molding fabrication method
US832794427 May 201011 Dic 2012Varel International, Ind., L.P.Whipstock attachment to a fixed cutter drilling or milling bit
US84030801 Dic 201126 Mar 2013Baker Hughes IncorporatedEarth-boring tools and components thereof including material having hard phase in a metallic binder, and metallic binder compositions for use in forming such tools and components
US84487262 Feb 201228 May 2013Baker Hughes IncorporatedDrill bits with bearing elements for reducing exposure of cutters
US84593808 Jun 201211 Jun 2013TDY Industries, LLCEarth-boring bits and other parts including cemented carbide
US84593828 Oct 201011 Jun 2013Baker Hughes IncorporatedRotary drill bits including bearing blocks
US846481410 Jun 201118 Jun 2013Baker Hughes IncorporatedSystems for manufacturing downhole tools and downhole tool parts
US847984218 Ene 20119 Jul 2013Joseph TucceriGarden auger
US849067419 May 201123 Jul 2013Baker Hughes IncorporatedMethods of forming at least a portion of earth-boring tools
US850083327 Jul 20106 Ago 2013Baker Hughes IncorporatedAbrasive article and method of forming
US851712325 May 201027 Ago 2013Varel International, Ind., L.P.Milling cap for a polycrystalline diamond compact cutter
US85617293 Jun 201022 Oct 2013Varel International, Ind., L.P.Casing bit and casing reamer designs
US863712727 Jun 200528 Ene 2014Kennametal Inc.Composite article with coolant channels and tool fabrication method
US864756125 Jul 200811 Feb 2014Kennametal Inc.Composite cutting inserts and methods of making the same
US865703614 Ene 201025 Feb 2014Downhole Products LimitedTubing shoe
US869725814 Jul 201115 Abr 2014Kennametal Inc.Articles having improved resistance to thermal cracking
US875265415 May 201317 Jun 2014Baker Hughes IncorporatedDrill bits with bearing elements for reducing exposure of cutters
US875729710 Jun 201324 Jun 2014Baker Hughes IncorporatedRotary drill bits including bearing blocks
US87572998 Jul 201024 Jun 2014Baker Hughes IncorporatedCutting element and method of forming thereof
US878962516 Oct 201229 Jul 2014Kennametal Inc.Modular fixed cutter earth-boring bits, modular fixed cutter earth-boring bit bodies, and related methods
US879043926 Jul 201229 Jul 2014Kennametal Inc.Composite sintered powder metal articles
US880084831 Ago 201112 Ago 2014Kennametal Inc.Methods of forming wear resistant layers on metallic surfaces
US88085911 Oct 201219 Ago 2014Kennametal Inc.Coextrusion fabrication method
US88410051 Oct 201223 Sep 2014Kennametal Inc.Articles having improved resistance to thermal cracking
US88588708 Jun 201214 Oct 2014Kennametal Inc.Earth-boring bits and other parts including cemented carbide
US8869919 *19 Abr 201128 Oct 2014Smith International, Inc.Drag bit with utility blades
US886992017 Jun 201328 Oct 2014Baker Hughes IncorporatedDownhole tools and parts and methods of formation
US888783917 Jun 201018 Nov 2014Baker Hughes IncorporatedDrill bit for use in drilling subterranean formations
US890511719 May 20119 Dic 2014Baker Hughes IncoporatedMethods of forming at least a portion of earth-boring tools, and articles formed by such methods
US894366315 Abr 20093 Feb 2015Baker Hughes IncorporatedMethods of forming and repairing cutting element pockets in earth-boring tools with depth-of-cut control features, and tools and structures formed by such methods
US897873419 May 201117 Mar 2015Baker Hughes IncorporatedMethods of forming at least a portion of earth-boring tools, and articles formed by such methods
US89787888 Jul 201017 Mar 2015Baker Hughes IncorporatedCutting element for a drill bit used in drilling subterranean formations
US901640630 Ago 201228 Abr 2015Kennametal Inc.Cutting inserts for earth-boring bits
US90164075 Dic 200828 Abr 2015Smith International, Inc.Drill bit cutting structure and methods to maximize depth-of-cut for weight on bit applied
US917432514 Jun 20133 Nov 2015Baker Hughes IncorporatedMethods of forming abrasive articles
US92661718 Oct 201223 Feb 2016Kennametal Inc.Grinding roll including wear resistant working surface
US929100221 Ene 201522 Mar 2016Baker Hughes IncorporatedMethods of repairing cutting element pockets in earth-boring tools with depth-of-cut control features
US9303460 *31 Ene 20135 Abr 2016Baker Hughes IncorporatedCutting element retention for high exposure cutting elements on earth-boring tools
US93097235 Oct 201012 Abr 2016Baker Hughes IncorporatedDrill bits and tools for subterranean drilling, methods of manufacturing such drill bits and tools and methods of directional and off center drilling
US942882219 Mar 201330 Ago 2016Baker Hughes IncorporatedEarth-boring tools and components thereof including material having hard phase in a metallic binder, and metallic binder compositions for use in forming such tools and components
US943501022 Ago 20126 Sep 2016Kennametal Inc.Composite cemented carbide rotary cutting tools and rotary cutting tool blanks
US9624732 *17 Jul 201418 Abr 2017First Corp International Inc.Hole opener and method for drilling
US964323611 Nov 20099 May 2017Landis Solutions LlcThread rolling die and method of making same
US9644428 *13 Abr 20099 May 2017Baker Hughes IncorporatedDrill bit with a hybrid cutter profile
US968796310 Mar 201527 Jun 2017Baker Hughes IncorporatedArticles comprising metal, hard material, and an inoculant
US97313586 Jun 201415 Ago 2017Milwaukee Electric Tool CorporationStep drill bit
US974464621 Sep 201529 Ago 2017Baker Hughes IncorporatedMethods of forming abrasive articles
US979074524 Nov 201417 Oct 2017Baker Hughes IncorporatedEarth-boring tools comprising eutectic or near-eutectic compositions
US20040216926 *4 Jun 20044 Nov 2004Dykstra Mark W.Drill bits with reduced exposure of cutters
US20040245022 *5 Jun 20039 Dic 2004Izaguirre Saul N.Bonding of cutters in diamond drill bits
US20050103533 *17 Nov 200319 May 2005Sherwood William H.Jr.Cutting element retention apparatus for use in steel body rotary drill bits, steel body rotary drill bits so equipped, and method of manufacture and repair therefor
US20050183892 *19 Feb 200425 Ago 2005Oldham Jack T.Casing and liner drilling bits, cutting elements therefor, and methods of use
US20050284660 *30 Ago 200529 Dic 2005Dykstra Mark WDrill bits with reduced exposure of cutters
US20060032335 *12 Oct 200516 Feb 2006Kembaiyan Kumar TBit body formed of multiple matrix materials and method for making the same
US20060048973 *9 Sep 20049 Mar 2006Brackin Van JRotary drill bits including at least one substantially helically extending feature, methods of operation and design thereof
US20060070771 *23 Sep 20056 Abr 2006Mcclain Eric EEarth boring drill bits with casing component drill out capability and methods of use
US20060150777 *14 Mar 200613 Jul 2006Sherwood William H JrMethods of manufacturing and repairing steel body rotary drill bits including support elements affixed to the bit body at least partially defining cutter pocket recesses
US20060278436 *21 Ago 200614 Dic 2006Dykstra Mark WDrilling apparatus with reduced exposure of cutters
US20070079995 *20 Sep 200612 Abr 2007Mcclain Eric ECutting elements configured for casing component drillout and earth boring drill bits including same
US20070108650 *24 Oct 200617 May 2007Mirchandani Prakash KInjection molding fabrication method
US20070151770 *12 Dic 20065 Jul 2007Thomas GanzDrill bits with bearing elements for reducing exposure of cutters
US20070158115 *20 Mar 200712 Jul 2007Sherwood William H JrMethods of manufacturing and repairing rotary drill bits including support elements affixed to the bit body at least partially defining cutter pocket recesses
US20070199739 *21 Feb 200730 Ago 2007Thorsten SchwefeCutting element insert for backup cutters in rotary drill bits, rotary drill bits so equipped, and methods of manufacture therefor
US20070261890 *10 May 200615 Nov 2007Smith International, Inc.Fixed Cutter Bit With Centrally Positioned Backup Cutter Elements
US20070284153 *23 Ago 200713 Dic 2007Baker Hughes IncorporatedRotary drag bit including a central region having a plurality of cutting structures
US20070289782 *11 May 200720 Dic 2007Baker Hughes IncorporatedReaming tool suitable for running on casing or liner and method of reaming
US20080105466 *2 Oct 20078 May 2008Hoffmaster Carl MDrag Bits with Dropping Tendencies and Methods for Making the Same
US20080142271 *20 Feb 200819 Jun 2008Baker Hughes IncorporatedMethods of designing rotary drill bits including at least one substantially helically extending feature
US20080149393 *30 Oct 200726 Jun 2008Baker Hughes IncorporatedEarth boring drill bits with casing component drill out capability and methods of use
US20080223575 *29 May 200818 Sep 2008Baker Hughes IncorporatedCasing and liner drilling bits and reamers, cutting elements therefor, and methods of use
US20080223622 *13 Mar 200718 Sep 2008Duggan James LEarth-boring tools having pockets for receiving cutting elements therein and methods of forming such pockets and earth-boring tools
US20080302575 *11 Jun 200711 Dic 2008Smith International, Inc.Fixed Cutter Bit With Backup Cutter Elements on Primary Blades
US20080308321 *14 Jun 200718 Dic 2008Enis AlikoInterchangeable bearing blocks for drill bits, and drill bits including same
US20090065263 *29 Ago 200812 Mar 2009Smith International, Inc.Drag bit with utility blades
US20090084608 *12 Feb 20082 Abr 2009Mcclain Eric ECutting structures for casing component drillout and earth boring drill bits including same
US20090107730 *29 Oct 200830 Abr 2009Green James CDrill bits and tools for subterranean drilling
US20090145669 *5 Dic 200811 Jun 2009Smith International, Inc.Drill Bit Cutting Structure and Methods to Maximize Depth-0f-Cut For Weight on Bit Applied
US20090158898 *27 Feb 200925 Jun 2009Baker Hughes IncorporatedMethods of manufacturing and repairing rotary drill bits including support elements affixed to the bit body at least partially defining cutter pocket recesses
US20090266619 *1 Abr 200929 Oct 2009Smith International, Inc.Fixed Cutter Bit With Backup Cutter Elements on Secondary Blades
US20100065282 *23 Nov 200918 Mar 2010Baker Hughes IncorporatedMethod of drilling out a reaming tool
US20100108390 *4 Nov 20086 May 2010Baker Hughes IncorporatedApparatus and method for controlling fluid flow in a rotary drill bit
US20100175930 *13 Abr 200915 Jul 2010Baker Hughes IncorporatedDrill Bit With A Hybrid Cutter Profile
US20100187011 *23 Oct 200929 Jul 2010Jurica Chad TCutting structures for casing component drillout and earth-boring drill bits including same
US20100193253 *30 Ene 20095 Ago 2010Massey Alan JEarth-boring tools and bodies of such tools including nozzle recesses, and methods of forming same
US20100224419 *3 Mar 20099 Sep 2010Baker Hughes IncorporatedDrill bit with integral cuttings splitter and method of making
US20100263937 *15 Abr 200921 Oct 2010Overstreet James LMethods of forming and repairing cutting element pockets in earth-boring tools with depth-of-cut control features, and tools and structures formed by such methods
US20100270077 *22 Abr 200928 Oct 2010Baker Hughes IncorporatedDrill bits and tools for subterranean drilling, methods of manufacturing such drill bits and tools and methods of off-center drilling
US20100270078 *28 Abr 200928 Oct 2010Baker Hughes IncorporatedMethod and apparatus to thwart bit balling of drill bits
US20100270087 *22 Abr 200928 Oct 2010Baker Hughes IncorporatedDrill bit with prefabricated cuttings splitter and method of making
US20100276200 *26 Abr 20104 Nov 2010Baker Hughes IncorporatedBearing blocks for drill bits, drill bit assemblies including bearing blocks and related methods
US20100307837 *3 Jun 20109 Dic 2010Varel International, Ind., L.P.Casing bit and casing reamer designs
US20100307838 *5 Jun 20099 Dic 2010Baker Hughes IncorporatedMethods systems and compositions for manufacturing downhole tools and downhole tool parts
US20100319996 *25 May 201023 Dic 2010Varel International, Ind., L.P.Milling cap for a polycrystalline diamond compact cutter
US20100319997 *27 May 201023 Dic 2010Varel International, Ind., L.P.Whipstock attachment to a fixed cutter drilling or milling bit
US20110024200 *8 Jul 20103 Feb 2011Baker Hughes IncorporatedCutting element and method of forming thereof
US20110079438 *5 Oct 20107 Abr 2011Baker Hughes IncorporatedDrill bits and tools for subterranean drilling, methods of manufacturing such drill bits and tools and methods of directional and off center drilling
US20110100721 *8 Oct 20105 May 2011Baker Hughes IncorporatedRotary drill bits including bearing blocks
US20110114392 *18 Oct 201019 May 2011Baker Hughes IncorporatedDrilling apparatus with reduced exposure of cutters and methods of drilling
US20110198128 *27 Abr 201118 Ago 2011Baker Hughes IncorporatedEarth-boring tools including abrasive cutting structures and related methods
US20110203850 *2 May 201125 Ago 2011Baker Hughes IncorporatedMethods of drilling using differing types of cutting elements
US20110210474 *11 May 20111 Sep 2011Baker Hughes IncorporatedDrill bit with integral cuttings splitter and method of making
US20110220312 *11 May 201115 Sep 2011Baker Hughes IncorporatedDrill bit with prefabricated cuttings splitter and method of making
US20110253457 *19 Abr 201120 Oct 2011Smith International, Inc.Drag bit with utility blades
US20130199857 *31 Ene 20138 Ago 2013Baker Hughes IncorporatedCutting element retention for high exposure cutting elements on earth-boring tools
US20160017666 *17 Jul 201421 Ene 2016First Corp International Inc.Hole opener and method for drilling
EP0119620A2 *19 Mar 198426 Sep 1984Eastman Christensen CompanyImproved tooth design using cylindrical diamond cutting elements
EP0119620A3 *19 Mar 198412 Feb 1986Norton Christensen, Inc.Improved tooth design using cylindrical diamond cutting elements
EP0121802A2 *11 Mar 198417 Oct 1984Eastman Christensen CompanyTooth configuration for an earth boring bit
EP0121802B1 *11 Mar 198428 Feb 1990Eastman Christensen CompanyTooth configuration for an earth boring bit
EP0169683A2 *8 Jul 198529 Ene 1986Reed Tool Company LimitedImprovements in or relating to rotary drill bits
EP0169683A3 *8 Jul 198511 Jun 1986Nl Petroleum Products LimitedImprovements in or relating to rotary drill bits
EP0822318A1 *22 Jul 19974 Feb 1998Camco International (UK) LimitedImprovements in or relating to rotary drill bits
EP2113049A4 *30 Ene 20082 Dic 2015Halliburton Energy Services IncRotary drill bits with protected cutting elements and methods
WO2015171199A1 *11 Mar 201512 Nov 2015Varel International Ind., L.P.Short matrix drill bits and methodologies for manufacturing short matrix drill bits
Clasificaciones
Clasificación de EE.UU.175/428
Clasificación internacionalE21B10/56, E21B10/573
Clasificación cooperativaE21B10/573
Clasificación europeaE21B10/573
Eventos legales
FechaCódigoEventoDescripción
21 Sep 1987ASAssignment
Owner name: EASTMAN CHRISTENSEN COMPANY, A JOINT VENTURE OF DE
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNORS:NORTON COMPANY;NORTON CHRISTENSEN, INC.;REEL/FRAME:004771/0834
Effective date: 19861230
Owner name: EASTMAN CHRISTENSEN COMPANY
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:NORTON COMPANY;NORTON CHRISTENSEN, INC.;REEL/FRAME:004771/0834
Effective date: 19861230